Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
APPARATUS AND METHOD FOR GAS-LIQUID SEPARATION
Field of the Invention
The present invention generally relates to the separation of components in a
multi-
phase flow stream. More specifically, it relates to restructuring flow regimes
by a flow
shaping apparatus so that the majority of a particular fluid component in a
flow stream is
located in a certain area of the flow stream, which allows for effective
separation of the
various fluid components.
Background of the invention
A gas-liquid two phase flow stream includes a mixture of different fluids
having
different phases, such as air and water, steam and water, or oil and natural
gas. Moreover,
the liquid phase of a fluid flow stream may further comprise different liquid
components,
such as oil and water. A gas-liquid two phase flow takes many different forms
and may be
classified into various types of gas distribution within the liquid. These
classifications are
commonly called flow regimes or flow patterns and are illustrated in Figs. lA
1E.
Rubble flow as illustrated in Figure lA is typically a continuous distribution
of liquid with
a fairly even dispersion of bubbles in the liquid. Slug or plug flow as
illustrated in Figure
IB is a transition from bubble flow where the bubbles have coalesced into
larger bubbles
with a size approaching the diameter of the tube. Churn flow as illustrated in
Figure IC is
a pattern where the slug flow bubbles have connected to one another. In
annular flow as
illustrated in Figure 11), liquid flows on the wall of the tube as a film and
the gas flows
along the center of the tube. Finally, in wispy annular flow as illustrated in
Figure 1E, as
the liquid flow rate is increased, the concentration of drops in the gas core
increases,
leading to the formation of large lumps or streaks of liquid.
it is often desirable to separate the gas and liquid components of a fluid
from one
another to enable proper operation of systems, such as certain types of liquid
pumps.
Conventional vertical or horizontal gas-liquid separators are available to
separate gas from
liquid. Conventional separators typically employ mechanical structures,
wherein an
incoming fluid strikes a diverting baffle which initiates primary separation
between the gas
and liquid components, Mesh pads or demister pads are then used to further
remove
suspended liquid. The sizing of a separator and the particular characteristics
of the
Date Recue/Date Received 2020-06-19
separator is dependent upon many factors, which may include, the flow rate of
the liquid,
the liquid density, the vapor density, the vapor velocity, and inlet pressure.
Vertical
separators are typically selected when. the vapor/liquid ratio is high or the
total flow rate is
low. Horizontal separators are typically preferred for low vapor/liquid ratio
or for large
volumes of total fluid.
One application of these types of separators is in oil and gas drilling
operations.
Specifically, a mud-gas separator is used when a kick is experienced in a
wellbore during
drilling operations. A kick is the flow of formation fluids into the wellbore
during drilling
operations. If a kick is not quickly controlled, it can lead to a blow out. As
part of the
process for controlling a kick, the blow-out preventors are activated to close
the wellbore
and wellbore fluids are slowly circulated out of the -wellbore While heavier
drilling fluids
are pumped into the wellbore. A mud gas separator is used to separate natural
gas from
drilling fluid as the .wellbore fluid is circulated out of the well:bore.
Often times, however,
prior art separators, have limited capability to process flow streams with
high volumes
and/or high flow rates, such as those characteristic of wellbores.
Of course, separators are also used in the production of oil and gas to
separate
natural gas from oil that is being produced. Additionally, there are many
other applications
that require the use of gas-liquid separators. For example, when supplying
fuel to ships,
known as bunkering, air i.s often entrained in the fuel, causing an inaccurate
measurement
of the transferred fuel. Likewise, in oil production or production of other
liquids,
transferring or conveying a liquid may result in the liquid acquiring
entrained gas during
that process, a result observed in pipelines with altered terrains. In this
regard, entrained
gasses can prevent the accurate measurement of a liquid product, whether it is
fuel
transferred during bunkering or a liquid flowing in a pipeline.
Summary of the Invention
One aspect of the invention relates to shaping multi-phase mixed flow using a
curvilinear flow line formed in multiple loops or coils prior to separation of
a fluid
component from the flow path. Shaping the multi-phase flow into a curvilinear
path will
allow centrifugal force to more readily force the heavier, denser liquid to
the outside or
outer diameter wall of the flow shaping line in the curved path and allow the
lighter, less
dense vapor or gas to flow along the inside or inner diameter wall of the flow
shaping line.
In certain embodiments, once a flow regime has been restructured within the
flow line, the
Date Recue/Date Received 2020-06-19
flow component collected adjacent a particular wall of the line can be
removed. For
example, in flow streams characterized by a larger liquid component, the gas
component of
a liquid-gas 'flow stream will, collect along the inner diameter wall of the
curved flow
shaping line, where the gas can be drawn or driven into an exit port located
on the inner
wall, thereby permitting a majority, if not all, of the gas, along with a low
amount of liquid,
to be sent to a conventional gas-liquid separator. The
separated fluid will have a
comparatively higher ratio of gas to liquid than the primary flow stream in
the flow line,
but will pass into the conventional gas separator at a flow rate much lower
than the total
flow rate within the flow shaping line. This permits for efficient separation
of the gas from
.10 the liquid
with the use of a smaller, more economical conventional gas-liquid separator
than what would have been required for the full flow stream and/or higher flow
rates.
In certain embodiments, a curvilinear flow line, whether in the form of a
single loop
or multiple loops, may be utilized in conjunction with a sensor for
controlling an adjustable
valve. In each case of multiple loops, the loops in the flow line permit an
extended
residence time of a flow stream through. the system. A sensor disposed along
the flow path
is utilized to estimate a property of the flow 12, such as for example, the
percentage or
"cut" of one or more components of the flow steam. The adjustable valve is
positioned
sufficiently downstream so that the valve can be timely adjusted based on the
measurement
from the sensor. For example, a sensor measuring cut can be utilized to adjust
the position
of a weir plate in the flow stream, thereby increasing or decreasing the
amount of fluid
separated from the flow stream. Although the sensors as described herein will
be primarily
described as measuring the cut, other types of sensors may also be utilized.
Likewise, the
type of cut sensors are not limited to a particular type, but may include the
non-limiting
examples of interface meters; optics or capacitance sensors. The extended
residence time
of the flow stream in the multi-loop system permits the valve to he adjusted
once the cut is
determined, thereby enhancing separation of fluid components once the flow
stream has
been restructured in accordance with the invention. The adjustable valve may
be, for
example, be a weir plate, foil or similar structure that can be used to draw
off or separate
one component of the flow stream. Other types of adjustable valves may also be
utilized.
In certain embodiments of a multi-loop system, the primary diameter of one or
more loops or coils generally disposed along an axis may be altered along the
length of the
axis to control the flow rate through the system. in certain embodiments, the
flow line will
include a plurality- of loops formed along an axis, with each successive loop
having a
3
Date Recue/Date Received 2020-06-19
smaller primary diameter than. the preceding loop, such that the velocity of
the flow stream
within the flow line increases along the axis while maintaining flow regime
separation.
Likewise, in certain embodiments, the flow line will include a plurality of
loops formed
along an axis, with each successive loop having a larger primary diameter than
the
preceding loop, such that the velocity of the flow stream within, the flow
line decreases
along the axis.
In certain embodiments of a multi-loop system, two sets of loops or coils may
be
utilized along a flow path. The first set of loops will function to separate a
component,
such as gas, as described above. The second set of loops functions to address
any gas that
remains in the flow stream. In certain embodiments, prior to introduction of
the flow
stream into the second set of loops, the flow stream may be agitated so as to
thereafter
enhance flow regime reshaping as described above.
Additionally, a fluid guiding surface may be placed on the inner wall of the
flow
shaping line at the exit port to further aid in directing the gas to flow to
the conventional
gas separator.
Furthermore, the liquid return from the conventional gas-liquid separator may
be
arranged in close downstream proximity to the exit port on the inner wall of
the flow
shaping line. The close proximity of the liquid return and the exit port
allows the use of a
venturi, nozzle or other restriction located adjacent the liquid return in the
flow shaping
line just downstream of the exit port. The venturi, nozzle or other
restriction accelerates
the velocity of the liquid in flow shaping line as it flows across the exit
port. This
acceleration of the liquid helps to pull the liquid out of the conventional
gas-liquid
separator. In addition, the acceleration of the liquid within the flow shaping
line helps to
prevent any solids that may be present in the gas-liquid flow from entering
the exit port and
it helps to lower the amount of liquid that enters the exit port and thus
enters the
conventional separator.
In certain embodiments, a heater may be disposed along a flow stream prior to
flow
regime reshaping in order to cause a phase change of at least a portion of the
fluid within
the flow stream. For example, certain liquid hydrocarbons in flow stream may
be
.. converted to gas under an applied heat in order to enhance separation of
the hydrocarbon
from the flow steam as described above. Such a heater may be utilized with
curvilinear
flow line having either single and multi-loops.
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Date Recue/Date Received 2020-06-19
Likewise, in certain embodiments, a curvilinear flow line having either single
and
multi-loops may be utilized in conjunction with a liquid-liquid phase
separator. The liquid-
liquid phase separator is preferably deployed down stream of the exit port and
is disposed
to separate different density liquids from one another. In certain
embodiments, the liquid-
liquid phase separator may be adjustable and utilized in conjunction with a
sensor. The
sensor is disposed along the flow path downstream of the gas exit port and is
utilized to
estimate the percentage or "cut" of various liquids remaining in the flow
steam. The phase
separator can be adjusted based on the cut. The phase separator may include,
for example,
an adjustable weir plate, adjustable foil, adjustable valve or similar
adjustable mechanism.
.10 in one
embodiment, the phase separator may include an adjustable valve in the form of
rotatable ball having two flow passages therethrough. Rotation of the ball
adjust the
positions of the flow passages relative to the liquid-liquid flow stream,
exposing more or
less of a particular passage to the flow steam. Other types of adjustable
valves may also be
In another embodiment of the invention particularly suited for flow streams
with a.
high gas content, i.e., "wet gas", a flow channel is formed along at least a
portion of the
inner diameter wall of a curvilinear flow line as described herein. The liquid
within the
wet gas will collect in the flow channel and can be drained off from the
primary flow
stream.
In another embodiment of the invention, the gas-liquid separator includes a
variable
position gas control valve that maintain.s level control of a vessel and
establishes a constant
flow pressure throughout the system.
The invention therefore allows a multi-phase fluid to be effectively separated
with
the use of a smaller conventional separator than was previously possible. The
invention
accomplishes this without using additional complex mechanical devices and thus
will
operate efficiently and reliably.
Brief Description of the Drawings
A more complete understanding of the present disclosure and advantages thereof
may be acquired by refeiTin.g to the following description taken in
conjunction with the
accompanying figures, wherein:
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Date Recue/Date Received 2020-06-19
Figures IA lE illustrate a cross-sectional view of various flow regimes of two
phase gas-liquid flow.
Figure 2 illustrates a cross-sectional view of an embodiment of separation
apparatus
with a flow regime modification loop/coil and a liquid-liquid phase splitter.
Figure 3 illustrates an elevation view of the embodiment of the separation
apparatus
with a plurality of flow regime modification loops/coils of descending cross-
sectional
diameter.
Figure 4 illustrates an elevation view of the embodiment of the separation
apparatus
with a plurality of flow regime modification loops/coils having successively
decreasing
diameters and a liquid-liquid phase separator.
Figure 5 illustrates an elevation view of the embodiment of the separation
apparatus
with a plurality of flow regime modification loops/coils having substantially
the same
diameters and a liquid-liquid phase separator.
Figure 6a illustrates an elevation view of the embodiment of the separation
apparatus with two sets of flow regime modification loops/coils of Figure 4,
Figure 6b illustrates an elevation view of the embodiment. of the separation
apparatus with two sets of flow regime modification loops/coils of Figure 5.
Figure 7 is an elevation view of a multi-phase flow separation apparatus
utilizing
two sets of loops/coils of Figure 4, arranged in series.
0 Figure. 8 illustrates a cross-sectional view of a flow regime
modification loop/coil
for wet gas processing.
Figure 9 illustrates a cross-sectional view of another embodiment of a liquid-
liquid
phase splitter with an adjustable valve.
Figure 10 illustrates a cross-sectional view of a gas control valve in a gas
separation
tank,
Figure 11 illustrates an elevation view of another embodiment of separation
apparatus deployed in oil and gas drilling operations.
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Date Recue/Date Received 2020-06-19
Figure 12 illustrates an elevation view of another embodiment of separation
apparatus deployed in fuel bunkering operations.
Detailed Description
In the detailed description of the invention, like numerals are employed to
designate
like parts throughout. Various items of equipment, such as pipes, valves,
pumps, fasteners,
fittings, etc., may be omitted to simplify the description. However, those
skilled in the art
will realize that such conventional equipment can be employed as desired.
Figure 2 illustrates a cross-sectional view of an embodiment of a separation
apparatus 10. In an exemplary embodiment, the separation apparatus 10 is in
fluid
communication with a main flow line 15 in which a multi-phase flow 12 is
traveling. The
multi-phase flow 12 could be any type of multiphase gas-liquid flow regime or
flow
pattern, such as, for example, bubble flow, slug or plug flow, chum flow,
annular flow or
wispy annular flow. Moreover, the multi-phase flow may include two components
within
a single phase, such as water and oil within the liquid phase. The multi-phase
flow 12
within main line 15 is directed into a curvilinear flow path 16 in a flow
shaping line 17. In
certain embodiments, such as is illustrated in Figure 2, the curvilinear flow
path 16 is
substantially in the form of a loop having a circular shape, although the
curvilinear flow
path may have other curvilinear shapes. in. any event, the curvilinear flow
path 16 of flow
shaping line 17 creates an increased distribution of a first phase 22, such as
gas, along the
inner wall 24 of the flow shaping line 17. The increased distribution of this
first phase 22
along the inner wall 24 of the flow shaping line 17 results in part by the
relatively heavier
and denser second phase 18, such as a liquid, of flow 12 being forced to the
outer wall 20
of the flow shaping line 17 due to centrifugal force of curvilinear flow path
16, while the
lighter first phase 22 is driven to the inner wall 24. The flow shaping line
17 may be
disposed in any orientation, including substantially in a vertical plane or a
horizontal plane.
In embodiments with a vertical or partly vertical orientation of the flow
shaping line 17,
gravitational effects may also aid in increasing the distribution of the first
phase 22 on the
inner wall 24 of the flow shaping line 17.
As the multi-phase flow 12 continues to travel through the curvilinear flow
path 16
of flow shaping line 17, the multi-phase flow 12 forms a flow path that
exhibits a high
concentration of gas 22 along the inner wall 24 of the flow shaping line 17.
In the
embodiment shown in Figure 2, at location 26, which is approximately 315
d.egrees around
7
Date Recue/Date Received 2020-06-19
shaping line 17 (or 45 degrees from the vertical), the separation of gas 22
from liquid 18
has reached a degree that gas 22 primarily occupies the space adjacent the
inner wall 24 of
the flow shaping line 17. As seen in Figure 3, which is a cross section 3-3 of
the flow
shaping line 17 and multi-phase flow 12 at location 26, the gas 22 occupies
mainly the
inner wall 24 of the circular flow path 16 of the flow shaping line 17 while
the liquid 18
primarily travels along the outer wall 20.
With gas-liquid flow 12 forming a more stratified flow regime, or at least the
distribution or volume of gas near the inner wall 24 of the flow shaping line
17 has
increased at the point of location 26, the gas 22 may be effectively bled off
from the gas-
liquid flow 12 at an outlet port 28 positioned along the inner wall 24 of the
flow shaping
line 17, preferably along a curvilinear portion of flow shaping line 17. In
this regard,
although outlet port 28 may be positioned anywhere along flow path 16, it is
preferably
selected to be at a point where substantial separation of gas from liquid has
occurred.
Thus, in one preferred embodiment, the outlet port 28 is downstream of
location 26. At
about a location 26, which is approximately at an angle of approximately 45
degrees from a
vertical axis 74 or otherwise, approximately 315 degrees about a circular flow
path, it has
been found that the concentration, separation or stratification of the gas 22
from the liquid
18 is at a point that gas 22 occupies a greater volume of space adjacent the
inner wall 24 of
the main line 15 than liquid 18. In other embodiments, the outlet port 28 may
be located
between generally 45 degrees from the vertical and generally zero degrees with
the
vertical. While location 26 is illustrated at approximately 315 degrees around
flow shaping
line 17 and has been found to be a point where a substantial volume of gas has
been driven
to inner wall 24, location 26 is used for illustrative purposes only. In this
regard, in
configurations with multiple loops formed by flow shaping line 17, the outlet
port 28 may
be disposed along an inner wall of any one of the loops, including the first
loop, the last
loop or an intermediate loop.
In an exemplary embodiment, a fluid guiding surface such as one of fluid
guiding
surfaces 30a or 30b is located at the outlet port 28. In certain embodiments,
a fluid
guiding surface 30a may be located on the inside diameter 32 of the inner wall
24 of the
flow shaping line 17 upstream of the outlet port 28. The fluid guiding
surfaces 30a and
30b include a downstream end 36 that curves around the corner 37 located at
the junction
of the outlet port 28 and the flow shaping line 17. The gas 22 follows the
contour of the
fluid, guiding surface 30a and the gas 22 will follow the curve of the
downstream end 36
into the outlet port 28. In another embodiment, a fluid guiding
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Date Recue/Date Received 2020-06-19
surface 30b may comprise a weir plate, foil or similar separation mechanism
disposed to
direct gas 22 into outlet port 28. The fluid guiding surface 30b functions to
guide the gas
22 into the outlet port 28. In certain embodiments, fluid guiding surface 30b
is adjustable
in order to adjust the position of fluid guiding surface 301,, and hence, the
first phase cut
removed from flow stream 12. A sensor 34 may be disposed to operate in
conjunction with
and control adjustable fluid guiding surface 30b based on a measured property
of the flow
stream 12, such as cut. Although sensor 34 may be located anywhere along main
line 15 or
flow shaping line 17, it has been found that sensor 34 is preferably separated
a sufficient
distance from outlet port 28 to permit the position of adjustable fluid
guiding surface 30b
to be adjusted once the cut of flow 12 has been determined. Likewise, in
certain
embodiments, sensor 34 is disposed along flow shaping line 17 at a point where
substantial
phase separation has taken place, such as at 26, thereby increasing the
accuracy of sensor
34.
An amount of liquid 18 from the gas-liquid flow 12 will also be carried into
the
outlet port 28 thus forming a new gas-liquid flow 40 which includes a much
lower
percentage of liquid 18 compared to the liquid 18 in gas-liquid flow 12. The
new gas-
liquid flow 40 from outlet port 28 is then directed into a conventional gas-
liquid separator
38, as shown in Figure 2, for further separation of the gas and liquid. Outlet
port 28 is
connected to the conventional gas-liquid separator by separator inlet line 33.
The gas-
.. liquid separator 38 contains a gas exit 39 to permit removal of gas 22
separated from flow
stream 12. The gas-liquid separator 38 also contains a liquid exit 41. In
certain
embodiments, liquid exit 41 that may be in fluid communication, via a line 44,
with flow
shaping line 17 or a subsequent flow line 43 disposed at the end of the flow
shaping line
17. Those skilled in the art will appreciate that separation apparatus 10 is
shown as
.. integrated with gas liquid separator 38, but can be a completely separate
structure.
In an exemplary embodiment, the liquid inlet port 42 is in close downstream
proximity to outlet port 28 with a venture or similar restriction 46 formed
therebetween
along the flow path of liquid 18 flow. The restriction 46 accelerates the
velocity of the
liquid 18 as it flows across the liquid inlet port 42. This acceleration of
liquid 18 lowers
the pressure of the liquid 18 flow in the primary flow path below that of the
liquid 18 in
line 44, thereby drawing liquid 18 out of the conventional gas-liquid
separator 38. In
addition, the acceleration of the liquid 18 facilitates separation of gas from
liquid within
flow shaping line 17, minimizes the likelihood that any solids present in the
gas-liquid flow
9
Date Recue/Date Received 2020-06-19
12 will enter outlet port 28, and minimizes the amount of liquid 18 that
enters the outlet
port 28.
In certain preferred embodiments, vantiri 46 is adjustable, permitting the
velocity
of the flow th.erethrough, and hence the pressure drop across the venturi 46,
to be adjusted
in order to control the amount of liquid 18 drawn from conventional gas-liquid
separator
38. This in turn, permits the pressure of the gas within gas-liquid separator
38, as well as
the proportional amounts of liquid and gas therein, to be controlled. This is
particularly
desirable when gas void fraction to liquid is a higher percentile. To
eliminate bypass of gas
that might pass extraction point 28.
As mentioned above, the efficient first step in the separation of the gas 22
from the
liquid 18 significantly decreases the amount of liquid 18 entering the
conventional gas-
liquid separator 38. This allows for the use of much smaller size conventional
gas-liquid
separators than would have previously been possible for a given flow rate
and/or flow
volume.
While circular flow path 16 is shown as positioned in a vertical plane, in
another
embodiment the circular flow path 16 could be in a horizontal plane (see
Figure 12) or in a
plane with an inclination between horizontal and vertical.
In certain embodiments, as further illustrated in Figure 2, a phase splitter
50 is in
fluid communication with flow shaping line 17 to receive the liquid 18 flow
therefrom.
Phase splitter 50 may be in direct fluid communication with flow shaping line
17 or may be
in communication with a flow line 43 disposed between the phase splitter 50
and flow
shaping line 17. In this regard, a flow line 43 may be utilized to stratify
multiple liquid
components within liquid 18 by stabilizing the fluid flow. For example, flow
line 43 may
be horizontally disposed so that liquids 18a with a first density, such as
oil, separate from
liquids 18b with a second density, such as water, by virtue of gravitational
effects acting
thereon. Alternatively, additional loops in flow shaping line 17 may be
utilized to stratify
the liquid components 18a, 18b.
Phase splitter 50 includes a housing having a liquid inlet 52 for receipt of
liquid 18,
as well as a first liquid outlet 54 and a second liquid outlet 56. A weir
plate, foil or similar
separation mechanism 58 is disposed within phase splitter 50 to direct a
portion of the
liquid 18 into first outlet 54 and allow a portion of the liquid 18 to pass
into second outlet
Date Recue/Date Received 2020-06-19
56. For example, weir plate 58 may be disposed to direct a substantial portion
of liquid
component 18b into first outlet 54, while allowing liquid component 18a to
pass over weir
plate 58 into second outlet 56. In this way, separation apparatus 10 may be
used not only
to separate gas from liquid,- but also to separate liquid from liquid in
instances where gas
and multiple liquids comprise flow stream 12.
In certain embodiments, separation mechanism 58 may be adjustable in order to
adjust the position of separation mechanism 58, and hence, the cut of liquid
removed from
liquid 18. Non-limiting examples of an adjustable separation mechanism 58
include an
adjustable valveõ adjustable weir plate or adjustable foil. A sensor 60 may be
disposed to
work in conjunction with and control an adjustable separation mechanism 58
based on a
measured property of liquid 18, such a cut, Although sensor 60 may be located
anywhere
along main line 15 or flow shaping line 17 or line 43, it has been found that
sensor 60 is
preferably separated a sufficient distance from separation mechanism 58 to
permit the
position of separation mechanism 58 to be adjusted once the property of flow
12 has been
determined.. Likewise, in certain, embodiments, sensor 60 is disposed along
flow shaping
line 17 or line 43 at a point where substantial liquid stratification has
taken place, thereby
increasing the accuracy of sensor 60. In certain embodiments, sensor 34 and
sensor 60
may be a single sensor utilized for multiple functions, such as to identify
the cut of gas, a
first liquid and a second liquid in flow 12.
Turning to Figure 4, other embodiments of the invention are illustrated. In
certain
embodiments, the curvilinear flow path 16 is substantially in the form of a
plurality of
loops Lf. . Li., each loop characterized by a diameter Di. Di that together
comprise flow
shaping line 17. The loops L are disposed along an axis 62. In certain
embodiments, the
diameter D of the loops L may remain substantially constant along the length
of axis 62,
while in other embodiments, the diameter of the loops may increase or
decrease, either
randomly or successively. In the illustrated embodiment, the diameter D of
successive
loops decrease along the length of the flow shaping line 17 from the first end
64 to the
second end 66 of flow shaping line 17.
The plurality of loops L may be provided to develop the increased
concentration of
the gas 22 on the inner wall 24 of the flow shaping line 17. Moreover, the
plurality of
loops I. increases the residence time of the flow 12 or liquid 18 through flow
shaping line
17. It may be desirable, for example, to increase residence time of the flow
12 or liquid 18
through the system 10 in order to measure the flow or liquid with sensors,
such as the
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Date Recue/Date Received 2020-06-19
sensors 34, 60 described above, and make adjustments to adjustable mechanisms
30b, 58
based on the measurements prior to the flow 12 or liquid 18 reaching the
adjustable
mechanism. For example, the phase splitter 50 may be adjusted to separate
liquid 18 into
multiple phases, or the foil 30b may be adjusted to separate gas 22 from flow
12.
In this same vein, it may be desirable to alter the rate of the flow 12 or
liquid 18
through system lO. This is achieved by increasing or decreasing the diameter D
of the
loops L to achieve a particular flow rate for a particular deployment of
system 10. In one
embodiment, for example, the diameter D of the loops L is decreased, resulting
in an
increase in velocity of the flow 12 from first end 64 to second end 66 which
thereby results
in greater centrifugal force and increased concentration of the gas 22 on the
inner wall 24
of the flow shaping line 17.
Sensors 34 and 60 may be disposed anywhere along the flow path of system 10 as
desired. Likewise, outlet 28 along inner wall 24 may be positioned anywhere
along flow
shaping line 17, the position being selected as desired based on the
components of flow 12.
Thus, outlet 28 may be positioned in the first loop Li or a subsequent loop L,
as illustrated.
Likewise, liquid inlet port 42 may be in fluid communication with flow shaping
line 17 or
line 43 at any point in order to reintroduce liquid 18 from separator 38 back
into the main
liquid 18 stream.
Figure 4 also illustrates an optional phase splitter 50 utilized in
conjunction with the
flow shaping line 17 shown. Figure 4 also illustrates an optional heater 68
utilized in
conjunction with flow shaping line 17. Heater 68 is particularly useful when
the flow 12
includes certain liquid components which are desirably removed as a gas
utilizing system
10. For example, certain liquid hydrocarbons, such as methane or gasses that
might move
from liquid to gas at different flash or boiling temperatures, may be present
in a flow 12
recovered from a wellbore (see Figure 11). Rather than recover the
hydrocarbons as
liquids, it may be desirable to heat the flow 12 using heater 68 to a
temperature where the
hydrocarbons convert to gas 22, after which the hydrocarbon gas 22 can be
removed
through outlet port 28 and separator 38.
Figure 5 illustrates the system 10 shown in Figure 4, but with all of the loop
diameters D approximately the same dimension. In the embodiment of Figure 5,
residence
time may be maintained while the adjustable mechanism 58 in phase splitter 50
is adjusted
based on one of the sensors 34, 60.
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Date Recue/Date Received 2020-06-19
Figure 6a illustrates the multi-loop system 10 shown in Figure 4, but with two
sets
of loops. In this case, a first flow shaping line 17a and a second flow
shaping line lib are
illustrated. Flow shaping lines 17a, 17b each have multiple loops L, Which
loops L may
have substantially the same diameter D or successively increasing or
decreasing diameters
Ii. The flow can be divided and. processed in parallel so that portions of the
flow stream
are simultaneously processed as described above, after which, the liquid from
each set of
loops can be recombined and directed towards outlet 72. Multiple sets of loops
arranged. in
parallel are particularly useful in cases of large flow volume
The system 10 of Figure 6b is the same as that of Figure 6a, but the loops L
have
substantially the same diameter D. The system of Figure 6b may also be used in
conjunction with a heater 68, cut sensors and adjustable cut mechanism 30b as
described
herein.
With reference to Figure 7, system 10 includes two sets of loops arranged in
series.
In this case, a first flow shaping line 17c and a second flow shaping line 17d
are illustrated.
Flow shaping lines 17e, 17d each have multiple loops L, which loops L may have
substantially the same diameter .D or successively increasing or decreasing
diameters D. In
the illustrated eathodiment, in each set of loops, the loops L have a
gradually decreasing
diameter along the curvilinear flow path 16. A heater 68 may be disposed to
convert part
of the flow 12 to a gaseous phase. Outlet port 28 to line 33 leading to
separator 38 is
positioned along the flow shaping line 17e at a point where it is expected a
substantial
amount of phase separation to have occurred after passing through at least a
portion of the
curvilinear flow path 176. A sensor 34 is positioned in order to measure a
property of the
flow 12. Sensor 34 is spaced apart along flow shaping line 17e a sufficient
distance to
allow the flow 112 to have a residence time in the loops prior to reaching
outlet port 28
positioned on inner wall 24, thereby permitting an adjustable separation
mechanism, such
as 30b shown in 'Figure 2, to be adjusted accordingly. First flow shaping line
17c is
intended, to remove a large portion of the gas 22 that comprises fluid flow
12. Thereafter,
the liquid 18 passes through line 43 and into the second flow shaping line 17d
to remove
remaining gas that may be within the flow exiting the first flow shaping line
17c. Again, a
sensor 34 may be utilized in conjunction with an adjustable separation
mechanism adjacent
outlet port 28 of second flow shaping line 17d.
In one configuration of the system :10 shown in Figure 7õ flow shaping lines
17d
operates as describe in Figure 2, passing a liquid comprised of substantially
first and
13
Date Recue/Date Received 2020-06-19
second liquid components 18a, 18 b into phase splitter 50. A sensor 60 may be
disposed
along flow shaping line 17d. to control an adjustment mechanism 58 disposed
within phase
splitter 50.
Multiple sets of loops are particularly useful in cases of large flow volume.
The
flow can be divided and processed in parallel so that portions of the flow
stream are
simultaneously processed. as described above, after which, the liquid from
each set of loops
can be recombined and directed towards outlet 72.
Turning to Figure 8, another embodiment of a flow shaping line 17 is
illustrated. In
this embodiment, flow shaping line 17 is shown in cross section and includes a
channel 74
formed along the inner wall 24 of at least a portion of the curvilinear flow
path 16.
Channel 74 may be utilized in any configuration of a flow shaping line 17
having a
curvilinear portion, including flow shaping line fomied in both single loop
and multiple
loop arrangements. It has been found that such systems 10 having a channel 74
are
particularly effective in multi-phase flow regimes with a high gas to liquid
content. In
other words, flow 1.2 is comprised primarily of gas 22, with a relative low
amount of liquid
18 suspended therein. As flow 12 follows the curvilinear shape of flow shaping
line 17,
the liquid 18 will become trapped within channel 74 and can be drained off
through an
outlet port 28 disposed along channel 74. Thereafter, the separated liquid may
be
introduced into a second curvilinear flow shaping line 17 without a channel xx
to permit
separation of gas from liquid as depicted and discussed in the foregoing
embodiments and
illustrations.
Figure 9 illustrates one embodiment of an adjustable separation mechanism 58
for
use in phase splitter 50. Adjustable separation mechanism 58 is a ball valve
76 having a
ball 78 rotatably mounted in a ball seat 80 carried within a phase splitter
housing 82. Ball
.. 78 includes a first passageway 84 having an inlet 86 and an outlet 88, as
well as a second
passageway 90 having an inlet 92 and an outlet 94. Passageways 84 and 90 are
formed in
ball 78 so that inlets 86, 92 are adjacent one another, while outlets 88, 94
are spaced apart
from one another. In one embodiment, passageways 84, 90 converge at inlets 86,
92 so
that a portion of bail 78 defining passageways 84, 90 forms an edge 96. As
previously
described, phase splitter 50 includes a liquid inlet 52, a first outlet 54 and
a second outlet
56. Ball valve 76 is disposed in seat 80 so that the inlets 86, 92 are
adjacent fluid inlet 52,
first ball outlet 88 is in fluid communication with first outlet 54 and second
bail outlet 94 is
in fluid communication with outlet 56. In a preferred embodiment, edge 96 is
positioned
14
Date Recue/Date Received 2020-06-19
adjacent inlet. 52_ Rotation of ball 78 thereby adjusts the position of edge
96 in liquid
stream 18 as liquid stream 18 flows across edge 96. In this way, valve 76 can
be adjusted
to alter the cut from liquid steam 18 such that a portion of the liquid 18a
flows through first
passageway 84 and a portion of the liquid 18b flows through the second
passageway 90.
Persons of ordinary skill in the art will understand that passageways 84, 90,
and their
respective inlets 86, 92 may be sized so that valve 76 may also be adjusted to
divert all of
18 flowing though inlet 52 into either first or second passageway 84, 90, as
desired.
With reference to Figure 10, a variable position gas control valve 98 is
placed on
the gas outlet 39 side of the two-phase separation vessel 38. The liquid
outlet 41 is
unregulated and allowed to drain. As gas is allowed to escape the level
increases in the
vessel and when gas is not allowed, to escape the level decreases. The
incoming flow 40 is
controlled and maintained at a specific level in separator 38 in order to
stabilize the
pressure therein so that liquid full flow bypass can be maintained without
peeks or
fluctuations in flow rate.
As described above, one application for the invention is to protect against
"kicks,"
such as in subsea applications, by circulating out hydrocarbon. gas at the
seabed floor
before the gas is able to rise up to a drilling rig. Referring to Figure 11,
in an exemplary
embodiment, illustrated is a conventional sub-sea blow out preventer 150
located on the
seafloor 152. A marine riser 154 extends from the blow out preventer 150 and
within the
riser is a drillpipe 156. One embodiment of the separation apparatus 110 is
positioned
along drillpipe 156, preferably adjacent the blow out preventer 150. In normal
drilling
operations, drilling fluid 158 is pumped down the drillpipe 156 from the
drilling rig 157
and returns to the drilling rig 157 via annulus 160 formed between the
drillpipe 156 and the
riser 154. If a "kick" is detected, such as by cut or similar sensors
described herein, inlet
annulus valve 162 is activated, diverting returning drilling fluid 158 from
annulus 160 into
the flow shaping line 117. Flow shaping line may have one or multiple sets of
coils. In the
case of a. single set of coils, flow shaping line is preferably arranged so
that successive
loops L along the line 117 having a decreasing diameter. In the case of
multiple sets of
coils, the flow shaping lines 117 may be arranged in parallel. Natural gas
entrained in
drilling fluid 158 from the "kick" is then separated from the drilling fluid
158 by the
separation apparatus 110 as described above. Specifically, gas will exit flow
shaping line
117 into a separator 138. The natural gas then exits the gas-liquid separator
138 at the gas
exit 139 and may flow up riser 166 to the drilling rig where it may be safely
handled, for
Date Recue/Date Received 2020-06-19
example, sent. to a flare boom of the drilling rig 157, or compressed and re-
distributed (also
not shown).
Following separation of natural gas from the recovered drilling fluid 158 by
separation apparatus 110, the drilling fluid .158 is re-introduced into the
annulus 160 at an
exit annulus valve 168. In comparison, with the usual procedure of handling a
kick, the use
of an embodiment of this invention allows for full flow or circulation of the
drilling fluid
without having to choke down the flow or operate the blow out preventer
valves,
In another embodiment, the inlet annulus valves 162 or exit annulus valves 168
can
be eliminated, bypassed or operated so that the upward flowing drilling fluid
158
continually flows through the separation apparatus 110. Compared to the usual
procedure
on a drilling rig when there is a kick of choking the flow of the drilling
fluid and being able
to only send a portion of the flow to the mud-gas separator located on the
drilling rig, an
embodiment of the present invention allows the full flow of the drilling fluid
to be handled
by the separation apparatus 110 and the separation safely takes place near the
seafloor.
in one embodiment, flow shaping line 1.17 may comprise multiple loops of
decreasing diameter as described above and illustrated in Figure 11. in
other
embodiments, flow shaping line 117 may comprise a single loop or multiple
loops of
substantially the same diameter, but utilized in conjunction with a heater 68
to convert
certain hydrocarbons to gas and/or a sensor 34 utilized in conjunction with an
adjustable
cut .mechanism 30b (see Figure 2), such as a foil, weir plate or valve.
In another embodiment illustrated in Figure 11, a separation. apparatus 210
having a
flow shaping line 211 is utilized in conjunction with drilling and a
hydrocarbon recovery
system near the ground or water surface 212. A fluid flow (such as fluid flow
12 in Figure
2) from a wellbore 216 is directed into flow shaping line 211 positioned
adjacent a drilling
rig 157. In normal drilling operations, drilling fluid 158 is pumped down a
drillpipe 156
from the drilling rig 157 and returns to the drilling rig 157 via. annulus 160
formed between
the thillpipe 156 and a pipe 154, such as a riser in the case of marine
drilling operations or
a well casing in the ease of land drilling operations. The recovered drilling
fluid 158 from
annulus 160 is directed into the flow shaping line 211. Preferably, drilling
mud and
cuttings are first removed from, the flow 214 using various systems 215 known
in the
industry before introduction into flow shaping line 211. Natural gas entrained
in drilling
fluid 158 is then separated from the drilling fluid 158 by the separation.
apparatus 210 as
16
Date Recue/Date Received 2020-06-19
described above. Specifically, gas will exit flow shaping line 211 into a
separator 238.
The natural gas 164 exits the gas-liquid separator 238 at the gas exit 239.
In one embodiment, flow shaping line 211 may comprise multiple loops of
decreasing diameter as described above and illustrated in Figure 4, in other
embodiments,
flow shaping line 211 may comprise a single loop or multiple loops of
substantially the
same diameter, but utilized in conjunction with a heater 68 to convert certain
hydrocarbons
to gas and/or a sensor 34 utilized in conjunction with an adjustable cut
mechanism, such as
a foil, weir plate or valve. Moreover, separation apparatus 210 may include a
phase splitter
220 in fluid communication with line 211 and disposed to separate liquid
components as
described above.
In another embodiment illustrated in Figure 12, a multi-phase flow separation
apparatus 310 can be utilized in bunkering operations to supply ships with
fuel. Bunker
fuel generally refers to any type of fuel oil used aboard ships. Bunker fuels
are delivered to
commercial ships via hunker barges, which often hold the bunker fuel in large
tanks 312.
The practice of delivering bunker .fuels is commonly referred to as
"bunkering", as such
bunker barges can also be known as bunkering barges. The bunker fuel is
typically pumped.
from the barge's tanks 312 to the tanks 314 on commercial ships. At times,
bunker fuels
may be transferred between bunker barges. In any event, the pumping of fuel in
bunkering
operations, especially as the vessels containing the fuel are emptied, larger
amounts of air
tend to be drawn in and pumped with the fuel, rendering pumping difficult and
resulting in
inaccurate measurements of fuel. Thus, in certain embodiments, a system 310 is
disposed
in line between a first fuel storage vessel 312 and the vessel to which the
fuel is being
pumped, namely a second fuel storage vessel 314. While system 310 may be of
many
different configurations as described herein, in certain, preferred
embodiments, system 310
includes, as shown in Figure 12, a curvilinear flow path 316 in a flow shaping
line 317.
Flow shaping line 317 includes a plurality of successive loops L of
substantially the same
diameter, each loop L being substantially horizontally disposed, thereby
twilling a "stack"
of loops L. It has been found that in the case of loops L. disposed
substantially in the
horizontal, the diameters of the loops, i.e., the coil sizes, do not need to
be successively
descending from the first end 364 of flow shaping line 317 to the second end
366 as is
desirable in vertical orientation of the loops. Thus, fuel is removed from the
first vessel
312, passed through system 310 and then directed to the second vessel 3.14.
The fuel
entering the first end 364 of flow shaping line 317 may have a large
proportion of air
17
Date Recue/Date Received 2020-06-19
included with the liquid fuel. The liquid fuel exiting the second end 366 of
flow shaping
line 317 has been substantially scru.bbed of the entrained air.
Although illustrative embodiments of the invention have been shown and
described, a wide range of modification, changes and substitution is
contemplated in the
foregoing disclosure. In some instances, some features of the present
invention may be
employed without a corresponding use of the other features, .Accordingly, it
is appropriate
that the appended claims be construed broadly and in a manner consistent with
the scope of
the invention.
18
Date Recue/Date Received 2020-06-19
